U.S. patent application number 12/540459 was filed with the patent office on 2010-02-18 for system and method for evaluation of structure-born sound.
This patent application is currently assigned to BAKER HUGHES INCORPORATED. Invention is credited to Dustin Garvey, Olof Hummes, Sven Krueger.
Application Number | 20100038135 12/540459 |
Document ID | / |
Family ID | 41669713 |
Filed Date | 2010-02-18 |
United States Patent
Application |
20100038135 |
Kind Code |
A1 |
Hummes; Olof ; et
al. |
February 18, 2010 |
SYSTEM AND METHOD FOR EVALUATION OF STRUCTURE-BORN SOUND
Abstract
A system for evaluation of conditions in a borehole in an earth
formation includes: a downhole tool configured to be disposed in
the borehole, the downhole tool forming a portion of a drillstring;
at least one sensor associated with the downhole tool for recording
sound generated in the borehole by the downhole tool and generating
data representative of the recorded sound, the recorded sound
having a frequency selected from at least one of an audible
frequency, a near audible frequency and an ultrasonic frequency;
and a processor in operable communication with the at least one
sensor, the processor configured to receive the sound data and
identify at least one downhole condition selected from at least one
of i) a drilling condition, ii) a characteristic of the earth
formation and iii) an integrity of the downhole tool, by comparing
the recorded sound data to exemplary data patterns.
Inventors: |
Hummes; Olof; (Wadersloh,
DE) ; Krueger; Sven; (Winsen, DE) ; Garvey;
Dustin; (Celle, DE) |
Correspondence
Address: |
CANTOR COLBURN LLP- BAKER HUGHES INCORPORATED
20 Church Street, 22nd Floor
Hartford
CT
06103
US
|
Assignee: |
BAKER HUGHES INCORPORATED
Houston
TX
|
Family ID: |
41669713 |
Appl. No.: |
12/540459 |
Filed: |
August 13, 2009 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
|
|
61088815 |
Aug 14, 2008 |
|
|
|
Current U.S.
Class: |
175/24 ; 175/50;
367/35 |
Current CPC
Class: |
E21B 49/003 20130101;
G01V 1/46 20130101 |
Class at
Publication: |
175/24 ; 175/50;
367/35 |
International
Class: |
E21B 47/00 20060101
E21B047/00; E21B 49/00 20060101 E21B049/00; E21B 44/00 20060101
E21B044/00; G01V 1/40 20060101 G01V001/40 |
Claims
1. A system for evaluation of conditions in a borehole in an earth
formation, the system comprising: a downhole tool configured to be
disposed in the borehole, the downhole tool forming a portion of a
drillstring; at least one sensor associated with the downhole tool
for recording sound generated in the borehole by the downhole tool
and generating data representative of the recorded sound, the
recorded sound having a frequency selected from at least one of an
audible frequency, a near audible frequency and an ultrasonic
frequency; and a processor in operable communication with the at
least one sensor, the processor configured to receive the sound
data and identify at least one downhole condition selected from at
least one of i) a drilling condition, ii) a characteristic of the
earth formation and iii) an integrity of the downhole tool, by
comparing the recorded sound data to exemplary data patterns.
2. The system of claim 1, wherein the recorded sound is generated
by contact between the earth formation and at least one of the
drillstring and a drill bit during a drilling operation.
3. The system of claim 1, further comprising a sound source
disposed within the downhole tool configured to emit sound waves
toward a surface of the downhole tool, the recorded sound data
being at least one of sound transmitted across a section of the
downhole tool and sound reflected from the surface of the downhole
tool.
4. The system of claim 1, wherein the sensor is at least one of a
piezoelectric sensor, an electromagnetic sensor, an electro-dynamic
sensor, an electrostatic sensor, a piezoresistive sensor and a
magnetostrictive sensor.
5. The system of claim 1, wherein generating data includes at least
one of: recording a spectral pattern of the sound over a selected
time period, and recording a relative change of phase and amplitude
between the generated sound and the recorded sound over a selected
time period.
6. The system of claim 5, wherein the processor is configured to
process the recorded sound via at least one of a statistic analysis
and a data fitting process.
7. The system of claim 5, wherein the processor is configured to
identify the downhole condition by comparing the sound data to
known exemplary spectral patterns representative of the downhole
condition.
8. The system of claim 1, wherein the processor is configured to
generate the exemplary data patterns by recording exemplary sound
waves associated with a known condition and generating an exemplary
spectral pattern associated with the known condition.
9. The system of claim 1, wherein the processor is configured to
transmit the recorded sound and the downhole condition to a
user.
10. The system of claim 1, wherein the processor is configured to
adjust a drilling parameter in response to identifying a selected
condition.
11. The system of claim 1, wherein disposing the downhole tool
includes at least one of drilling the borehole and lowering the
downhole tool in the borehole after a drilling operation.
12. A method of evaluating conditions in a borehole in an earth
formation, the method comprising: disposing a downhole tool in the
borehole, the downhole tool forming a portion of a drillstring;
recording sound generated in the borehole by at least one sensor
associated with the downhole tool, the sound having a frequency
selected from at least one of an audible frequency, a near audible
frequency and an ultrasonic frequency; generating data
representative of the sound; and identifying at least one downhole
condition selected from at least one of i) a drilling condition,
ii) a characteristic of the earth formation and iii) an integrity
of the downhole tool by comparing the recorded sound data to
exemplary data patterns.
13. The method of claim 12, wherein the sound is generated by
contact between the earth formation and at least one of the
drillstring and a drill bit during a drilling operation.
14. The method of claim 12, further comprising emitting sound waves
from a sound source disposed within the tool, the recorded sound
data being at least one of sound transmitted across a section of
the downhole tool and sound reflected from a surface of the
downhole tool.
15. The method of claim 12, wherein generating data includes at
least one of: recording a spectral pattern of the sound over a
selected time period, and recording a relative change of phase and
amplitude between the generated sound and the recorded sound over a
selected time period.
16. The method of claim 15, wherein generating data includes
processing the recorded sound via at least one of a statistic
analysis and a data fitting process.
17. The method of claim 11, further comprising generating the
exemplary data patterns by recording exemplary sound waves
associated with a known condition and generating an exemplary
spectral pattern associated with the known condition.
18. The method of claim 15, wherein identifying the condition
includes processing the recorded spectral pattern into a plurality
of functional parameters, and comparing the functional parameters
to exemplary functional parameters associated with a known
condition.
19. The method of claim 11, further comprising transmitting the
recorded sound and the downhole condition to a user.
20. The method of claim 11, further comprising adjusting a drilling
parameter in response to identifying a selected condition.
Description
CROSS-REFERENCE TO RELATED APPLICATIONS
[0001] This application claims the benefit of U.S. Provisional
Application Ser. No. 61/088,815, entitled "System and Method for
Evaluation of Structure-Born Sound", filed Aug. 14, 2008, under 35
U.S.C. .sctn.119(e), and which is incorporated herein by reference
in its entirety.
BACKGROUND
[0002] During drilling and/or FE operations, the integrity of
components of the drillstring, such as drill bit assemblies and
other downhole tools, is affected by various forces caused by
downhole conditions and interaction with an earth formation.
Various dynamic measurements are taken to diagnose process
conditions, such as drilling dynamics and dysfunctions such as
stick slip, whirl and bit bounce. For this purpose, tool movements
along specific axes are measured for instance using magnetometers
or accelerometers.
[0003] Component wear and other conditions, such as contact with a
hard formation feature, pose significant threats to the integrity
of downhole components. Such conditions can lead to, for example,
component failure, flooding and loss of components that delay
drilling operations and result in equipment and income loss. Such
conditions should be detected as soon as possible so that
appropriate action can be taken to prevent damage to the downhole
components.
BRIEF DESCRIPTION OF THE INVENTION
[0004] A system for evaluation of conditions in a borehole in an
earth formation includes: a downhole tool configured to be disposed
in the borehole, the downhole tool forming a portion of a
drillstring; at least one sensor associated with the downhole tool
for recording sound generated in the borehole by the downhole tool
and generating data representative of the recorded sound, the
recorded sound having a frequency selected from at least one of an
audible frequency, a near audible frequency and an ultrasonic
frequency; and a processor in operable communication with the at
least one sensor, the processor configured to receive the sound
data and identify at least one downhole condition selected from at
least one of i) a drilling condition, ii) a characteristic of the
earth formation and iii) an integrity of the downhole tool, by
comparing the recorded sound data to exemplary data patterns.
[0005] A method of evaluating conditions in a borehole in an earth
formation includes: disposing a downhole tool in the borehole, the
downhole tool forming a portion of a drillstring; recording sound
generated in the borehole by at least one sensor associated with
the downhole tool, the sound having a frequency selected from at
least one of an audible frequency, a near audible frequency and an
ultrasonic frequency; generating data representative of the sound;
and identifying at least one downhole condition selected from at
least one of i) a drilling condition, ii) a characteristic of the
earth formation and iii) an integrity of the downhole tool by
comparing the recorded sound data to exemplary data patterns.
BRIEF DESCRIPTION OF THE DRAWINGS
[0006] The following descriptions should not be considered limiting
in any way. With reference to the accompanying drawings, like
elements are numbered alike:
[0007] FIG. 1 depicts an embodiment of a well drilling and/or
logging system;
[0008] FIG. 2 depicts an embodiment of a system for evaluating
structure-born sound;
[0009] FIG. 3 depicts an embodiment of a system for evaluating
structure-born sound; and
[0010] FIG. 4 is a flow chart providing an exemplary method for
evaluating structure-born sound.
DETAILED DESCRIPTION OF THE INVENTION
[0011] There is provided a system and method for monitoring
conditions and/or characteristics of an earth formation and/or a
downhole tool or other component of a drillstring. The system and
method utilize sound waves generated by interaction between a drill
bit and the formation, contact between drillstring components and a
side of the borehole and/or sound waves reflected from a
drillstring component. In one embodiment, the sound waves have a
frequency in the audible, near audible and/or ultrasonic range. In
one embodiment, "near audible" refers to a frequency in the range
of approximately 1 Hz to 20 Hz. One or more sensors disposed in the
downhole tool generate data representative of received sound waves,
which is utilized to derive a drilling condition, a characteristic
or change in a characteristic of the earth formation and/or an
integrity of the downhole tool. A characteristic of the earth
formation, such as rock composition and texture, may be referred to
as a "lithology" characteristic.
[0012] Referring to FIG. 1, an exemplary embodiment of a well
drilling and/or logging system 10 includes a drillstring 11 that is
shown disposed in a borehole 12 that penetrates at least one earth
formation 14 during a drilling operation and makes measurements of
properties of the formation 14 and/or the borehole 12 downhole. In
one embodiment, such measurements are of sound waves generated in
the borehole 12 and/or the drillstring 11 that are used to monitor
lithology characteristics and/or conditions of components of the
drillstring 11. Drilling fluid, or drilling mud 16 may be pumped
through the drillstring 11 and/or the borehole 12. The well
drilling system 10 also includes a bottomhole assembly (BHA)
18.
[0013] As described herein, "borehole" or "wellbore" refers to a
single hole that makes up all or part of a drilled well. As
described herein, "formations" refer to the various features and
materials that may be encountered in a subsurface environment.
Accordingly, it should be considered that while the term
"formation" generally refers to geologic formations of interest,
that the term "formations," as used herein, may, in some instances,
include any geologic points or volumes of interest (such as a
survey area). In addition, it should be noted that "drillstring" as
used herein, refers to any structure suitable for lowering a tool
through a borehole or connecting a drill to the surface, and is not
limited to the structure and configuration described herein.
[0014] In one embodiment, the BHA 18 includes a drill bit assembly
20 and associated motors adapted to drill through earth formations.
The drill bit assembly 20 is powered by a surface rotary drive, a
motor using pressurized fluid (e.g., a mud motor), an electrically
driven motor and/or other suitable mechanism.
[0015] In one embodiment, the drill bit assembly 20 includes a
steering assembly including a steering motor 22 configured to
rotationally control a shaft 24 connected to a drill bit 26. The
shaft is utilized in geosteering operations to steer the drill bit
26 and the drillstring 11 through the formation 14.
[0016] In one embodiment, the BHA 18 is disposed in the well
logging system 10 at or near the downhole portion of the
drillstring 11. The BHA 18 includes any number of downhole tools 28
for various processes including formation drilling, geosteering,
and formation evaluation (FE) for measuring versus depth and/or
time one or more physical quantities in or around a borehole.
[0017] The downhole tool 28, in one embodiment, includes one or
more sensors or receivers 30 to measure frequencies of sound waves
generated in the downhole environment. Such sound waves, in one
embodiment, are in the audible, near audible and/or ultrasonic
frequency range. Examples of a sensor 30 include piezoelectric
electromagnetic, electro-dynamic, electrostatic, piezoresistive and
magnetostrictive sensors.
[0018] In one embodiment, the sound waves are generated by contact
between portions of the drillstring 11 and the formation 14, such
as during interaction between the drill bit 26 and the formation
14.
[0019] In another embodiment, sound waves such as ultrasonic waves
are generated by a sound source 32 disposed within the tool 28 and
configured to emit sound waves at a selected frequency. Such
sources include, for example, magnetostrictive and piezoelectric
transducers.
[0020] Referring to FIG. 2, examples of configurations of the sound
source 32, i.e., transmitter, and the sensor 30, i.e., receiver,
located within or on the tool 28 are shown. In each configuration,
the sound source 32 emits sound waves 36 that reflect off of a
location of the tool 28 which includes a feature or material defect
3 8 such as a crack. The reflected sound waves 36 are received and
measured by the sensor 30. Although the embodiments shown herein
include a single emitter and receiver, any number of emitters and
receivers may be utilized.
[0021] Referring again to FIG. 1, the data provided by these
sensors 30 is utilized to monitor various downhole conditions. Such
downhole conditions include drilling conditions, lithology
characteristics and an integrity condition of the downhole tool 28.
"Drilling conditions" refers to various drilling parameters of the
drillstring, such as drill bit 26 rotational speed, drillstring 11
rotational speed, axial acceleration, tangential acceleration,
lateral acceleration, torsional acceleration, bending moments,
drill bit whirl, drill bit bouncing, drill bit cutting efficiency,
stick-slip conditions. "Lithology characteristics" refers to
characteristics of the formation 14. "Integrity" of the downhole
tool 28 refers to the operable condition of components of the tool
28, e,.g., the existence of excessive wear or cracks. These
downhole conditions are identified via the recorded sound data to
allow drilling parameters to be adjusted to avoid damage to the
drillstring components.
[0022] For example, cracks or wear on the tool 28, indicative in a
loss of integrity, cause a shift in the frequency, phase or
amplitude of reflected sound waves, which is detectable by the
sensor 30. The frequency of sound generated by interactions between
the tool 28 or the drill bit 26 and the formation 14 can provide an
indication of the formation type currently drilled as well as an
indication of drilling efficiency.
[0023] Each of the sensors 30 may be a single sensor or multiple
sensors located at a single location or at multiple locations. In
one embodiment, one or more of the sensors 30 include multiple
sensors located proximate to one another and assigned a specific
location on the drillstring 11. Furthermore, in other embodiments,
each sensor 30 includes additional components, such as clocks,
memory processors, etc. In one embodiment, multiple sensors are
utilized and connected to a suitable noise subtraction circuit to
eliminate or compensate for noise signals.
[0024] The downhole tool 28, in one embodiment, includes one or
more additional sensors or receivers 30 to measure various
additional properties of the formation 14. Such sensors 30 include,
for example, nuclear magnetic resonance (NMR) sensors, resistivity
sensors, porosity sensors, gamma ray sensors, seismic receivers and
others. In other embodiments, the downhole tool 28 includes
suitable sensors for measuring drilling conditions such as
torque-on-bit, weight-on-bit, rotational speed and low frequency
dynamics. Such measurements can be used in conjunction with the
sound measurements to provide additional information, such as
identifying various phases of the drilling operations, e.g., on and
off bottom operation, reaming and steering.
[0025] The sound measurements, and optionally additional data
generated by additional sensors, are utilized to adjust various
loads on selected components of the drillstring 1 1. Such loads
include various mechanical loads related to drilling parameters
associated with drilling the borehole 12. Examples of such drilling
parameters include such as a weight on the drill bit 26, torque on
the drill bit 26, drilling fluid 16 flow through the drillstring
11, pressure, drill bit 26 rotational speed, drillstring 11
rotational speed, axial acceleration, tangential acceleration,
lateral acceleration, torsional acceleration, and bending moments.
Although the sensors 30 described herein are shown as part of the
BHA 18, the sensors 30 are disposable at any selected location or
locations in the drillstring 11.
[0026] In one embodiment, the taking of measurements from the
sensors 30 is recorded in relation to the depth and/or position of
the downhole tool 28, which is referred to as "logging", and a
record of such measurements is referred to as a "log". Examples of
logging processes that can be performed by the system 10 include
measurement-while-drilling (MWD) and logging-while-drilling (LWD)
processes, during which measurements of properties of the
formations and/or the borehole are taken downhole during or shortly
after drilling. The data retrieved during these processes may be
transmitted to the surface, and may also be stored with the
downhole tool for later retrieval. Other examples include logging
measurements after drilling, wireline logging, and drop shot
logging.
[0027] In one embodiment, the tool 28 is equipped with transmission
equipment to communicate ultimately to a surface processing unit
34. Such transmission equipment 34 may take any desired form, and
different transmission media and connections may be used. Examples
of connections include wired pipe, fiber optic, wireless
connections or mud pulse telemetry.
[0028] In one embodiment, the surface processing unit 34 and/or the
tool 28 include components as necessary to provide for storing
and/or processing data collected from the sensor(s) 30. Exemplary
components include, without limitation, at least one processor,
storage, memory, input devices, output devices and the like. The
surface processing unit 34 optionally is configured to control the
tool 28.
[0029] Referring to FIG. 3, there is provided a system 40 for
evaluating structure-born sound used in conjunction with the BHA 18
and/or the drillstring 11. The system 40 may be incorporated in a
computer or other processing unit capable of receiving data from
the tool 28. The processing unit may be included with the tool 28
or included as part of the surface processing unit 34.
[0030] In one embodiment, the system 40 includes a computer 42
coupled to the tool 28. Exemplary components include, without
limitation, at least one processor, storage, memory, input devices,
output devices and the like. As these components are known to those
skilled in the art, these are not depicted in any detail herein.
The computer 42 may be disposed in at least one of the surface
processing unit 34 and the tool 28.
[0031] Generally, some of the teachings herein are reduced to an
algorithm that is stored on machine-readable media. The algorithm
is implemented by the computer 42 and provides operators with
desired output.
[0032] In one embodiment, the computer 42 includes one or more
analysis units that compare received data to previously trained
data to identify specific conditions. The analysis units produce
spectral patterns of measured sound waves and generate condition
identifications based on comparison with exemplary spectral
patterns representative of known conditions. In one embodiment, the
system 40 is a nonparametric fuzzy inference system (NFIS). The
NFIS is a fuzzy inference system (FIS) whose membership function
centers and parameters are observations of exemplar inputs and
outputs.
[0033] FIG. 4 illustrates a method of evaluating structure-born
sound using a downhole tool in conjunction with a drillstring. The
method includes stages 51-54 described herein. The method may be
performed continuously or intermittently as desired. The method is
described herein in conjunction with the downhole tool 28, although
the method may be performed in conjunction with any number and
configuration of sensors and tools, as well as any device for
lowering the tool and/or drilling a borehole. The method may be
performed by one or more processors or other devices capable of
receiving and processing measurement data, such as the computer 42.
In one embodiment, the method includes the execution of all of
stages in the order described. However, certain stages may be
omitted, stages may be added, or the order of the stages
changed.
[0034] In the first stage 51, the downhole tool 28 is operated to
drill the borehole 12. The operation includes various drilling
operations such as reaming and geosteering, as well as any desired
measurement operating such as LWD operations. In one embodiment,
the downhole tool 28 is lowered into the borehole 12 subsequent to
a drilling operation.
[0035] In the second stage 52, structure-born sound is recorded via
the sensors 30. In one embodiment, the structure-born sound is in
the audible, near audible and/or ultrasonic range. In one
embodiment, the structure-born sound includes one or more of i)
sound generated by the interaction between the drill bit 26 and the
formation 14 during drilling, ii) sound generated by contact
between any drillstring 11 components and a sidewall of the
borehole 12 and iii) sound generated by source 32 and reflected
from a portion of the drillstring 11.
[0036] In the third stage 53, a spectral pattern of the recorded
sound is recorded. As referred to herein, a "spectral pattern"
refers to a pattern of frequencies over a selected time period. In
one embodiment, a relative change of phase and amplitude of emitted
and recorded sound is recorded over a selected time period.
[0037] In alternative embodiments, the phase, amplitude and/or
frequency response to a defined excitation signal are recorded over
time. In one embodiment, excitation signal includes sound waves
having a defined initial phase, amplitude and frequency, and the
response includes the sound waves reflected from a structure.
[0038] In one embodiment, prior to utilizing the system 30 for
evaluating structure-born sound, the analysis units are trained
based on data 60 known to be associated with specific conditions.
For example, the system is trained by building a case base in the
memory. Such conditions include, in one embodiment, lithology
characteristics, drilling conditions and/or tool conditions. Such
training includes recording exemplary spectral patterns
representative of known conditions.
[0039] In one embodiment, the data for each exemplary sound signal
is processed to produce exemplary spectral distribution patterns
representative of different conditions, such as different
lithologies, different levels and types of tool wear, and different
drilling conditions.
[0040] In one embodiment, each spectral pattern, i.e., both the
exemplary spectral patterns and the recorded spectral patterns, is
processed by suitable algorithms, regression and classification
algorithms or similar to compare raw or processed data to known
signatures that are typical for a certain condition. Such
processing includes methods such as statistical analysis and data
fitting to produce a data curve. Examples of statistical analysis
include calculation of a summation, an average, a variance, a
standard deviation, t-distribution, a confidence interval, and
others. Examples of data fitting include various regression
methods, such as linear regression, kernel regression, least
squares, segmented regression, hierarchal linear modeling, and
others.
[0041] In one embodiment, the exemplary spectral patterns and
recorded spectral patterns are represented by several functional
parameters representing a selected condition. An example of such
functions are Gaussian representations of the frequency
distribution or other suitable functional distributions. Each of
the Gaussians is described by its amplitude, its width, and its
mean. In one embodiment, the functional parameters are determined
via a regression method such as partial least-squares (PLS),
principal component regression (PCR), inverse least-squares (ILS),
or ridge regression (RR). The Gaussians can be used to reconstruct
the recorded spectral pattern and the corresponding representation
in the frequency domain which then can be used to compare the
recorded data to functional parameters of exemplary spectral
patterns. In another embodiment, the exemplary spectral patterns
are processed according to any suitable data reduction method, such
as Fourier analysis or wavelet analysis. Other examples include
principal components analysis.
[0042] In the fourth stage 54, the recorded spectral pattern is
classified based on a comparison with known patterns associated
with known lithology characteristics, drilling conditions and/or
tool conditions. In one embodiment, the analysis units determine
which of the exemplary spectral patterns are most similar to each
observed query observation.
[0043] In one embodiment, "nearest neighbor" (NN) classification is
utilized to determine which exemplary spectral pattern is
associated with the recorded spectral pattern. NN classification
includes assigning to an unclassified sample point the
classification of the nearest of a set of previously classified
points. An example of nearest neighbor classification is k-nearest
neighbor (kNN). kNN refers to the classifier that examines the
number "k" of nearest neighbors of a recorded pattern, and NN
refers to the classifier that examines the closest neighbor (i.e.
k=1). NN classification includes calculating a distance between a
recorded spectral pattern and each exemplary spectral pattern, and
associating the recorded pattern with a condition that is
associated with the exemplary spectral pattern having the smallest
distance.
[0044] In one embodiment, threshold values for identifying selected
conditions are determined. In one example, selected conditions are
defined during training, and a number of threshold values are
identified as associated with each condition.
[0045] In the fifth stage 55, the recorded spectral pattern and/or
the associated condition is transmitted to the surface to inform
the operator and indicate whether any corrective action is
necessary. Manual or automatic adjustment of drilling parameters is
performed or other corrective action is taken if needed. It can
also be used in a downhole processing unit to allow automatic
adjustment of tool parameters, such as steer force or center force,
in order to correct for the detected condition. In a further
embodiment, corrective action may be automatically initiated based
on the identified downhole conditions and predetermined decision
rules.
[0046] In one embodiment, the method 50 is performed during the
drilling operation and yields real time information regarding
downhole conditions. As used herein, generation of data in
"real-time" is taken to mean generation of data at a rate that is
useful or adequate for making decisions during or concurrent with
processes such as production, experimentation, verification, and
other types of surveys or uses as may be opted for by a user or
operator. As a non-limiting example, real-time measurements and
calculations may provide users with information necessary to make
desired adjustments during the drilling process. In one embodiment,
adjustments are enabled on a continuous basis (at the rate of
drilling), while in another embodiment, adjustments may require
periodic cessation of drilling for assessment of data. Accordingly,
it should be recognized that "real-time" is to be taken in context,
and does not necessarily indicate the instantaneous determination
of data, or make any other suggestions about the temporal frequency
of data collection and determination.
[0047] The systems and methods described herein provide various
advantages over prior art techniques. The system and method
described herein, by analyzing the drilling noise and other sound
generated during drilling, allows for a very fast way to identify
any changes in condition, e.g., providing instantaneous information
when a hard formation feature is encountered that could damage the
tool or lead to undesired wellpath deviations. The measurement
could be used to identify fractures or thin layers, and monitoring
of material integrity in critical areas could provide additional
safety against flooding or losing components in the borehole.
[0048] In support of the teachings herein, various analyses and/or
analytical components may be used, including digital and/or analog
systems. The system may have components such as a processor,
storage media, memory, input, output, communications link (wired,
wireless, pulsed mud, optical or other), user interfaces, software
programs, signal processors (digital or analog) and other such
components (such as resistors, capacitors, inductors and others) to
provide for operation and analyses of the apparatus and methods
disclosed herein in any of several manners well-appreciated in the
art. It is considered that these teachings may be, but need not be,
implemented in conjunction with a set of computer executable
instructions stored on a computer readable medium, including memory
(ROMs, RAMs), optical (CD-ROMs), or magnetic (disks, hard drives),
or any other type that when executed causes a computer to implement
the method of the present invention. These instructions may provide
for equipment operation, control, data collection and analysis and
other functions deemed relevant by a system designer, owner, user
or other such personnel, in addition to the functions described in
this disclosure.
[0049] Further, various other components may be included and called
upon for providing aspects of the teachings herein. For example, a
sample line, sample storage, sample chamber, sample exhaust, pump,
piston, power supply (e.g., at least one of a generator, a remote
supply and a battery), vacuum supply, pressure supply,
refrigeration (i.e., cooling) unit or supply, heating component,
motive force (such as a translational force, propulsional force or
a rotational force), magnet, electromagnet, sensor, electrode,
transmitter, receiver, transceiver, controller, optical unit,
electrical unit or electromechanical unit may be included in
support of the various aspects discussed herein or in support of
other functions beyond this disclosure.
[0050] One skilled in the art will recognize that the various
components or technologies may provide certain necessary or
beneficial functionality or features. Accordingly, these functions
and features as may be needed in support of the appended claims and
variations thereof, are recognized as being inherently included as
a part of the teachings herein and a part of the invention
disclosed.
[0051] While the invention has been described with reference to
exemplary embodiments, it will be understood by those skilled in
the art that various changes may be made and equivalents may be
substituted for elements thereof without departing from the scope
of the invention. In addition, many modifications will be
appreciated by those skilled in the art to adapt a particular
instrument, situation or material to the teachings of the invention
without departing from the essential scope thereof Therefore, it is
intended that the invention not be limited to the particular
embodiment disclosed as the best mode contemplated for carrying out
this invention, but that the invention will include all embodiments
falling within the scope of the appended claims.
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